Strategic Review April 2013

Strategic Review April 2013

Disclaimer The information contained in this presentation, which may include certain forward-looking information, is not to be relied upon for any particular purpose, and is not intended to be and shall not be deemed to be an offer, invitation or inducement to invest in or to sell or otherwise deal in any securities of Ruspetro plc or in any other investment, nor to provide or constitute any advice or recommendation in connection with any investment decision. Ruspetro plc makes no representation or warranty express or implied that the information or any such forward-looking information included in this presentation is accurate, comprehensive, verified or complete or of a satisfactory quality, or fitness for a particular purpose. Neither Ruspetro plc nor any other person or entity accepts liability for any loss of whatsoever nature or howsoever caused, arising directly or indirectly from the use of or reliance upon this presentation or any of the information it contains. The intellectual property rights in this presentation and the information within belong to and remain with Ruspetro plc. Unless provisions to the contrary have been agreed with Ruspetro plc no party shall be permitted to reproduce, make available to third parties or publish this presentation or any part of the same or the information contained in it, in any form or manner. 2

Table of Contents 1. Overview 2. 2012 Field Review 3. Development Plan 4. Financing Plan 5. 2012 Financial Review 3

1. Overview 4

West Siberian Producer with Significant Reserve Base Large on-shore reserve base Ruspetro s blocks Neighbouring blocks Krasnoleninsky Arch Proved reserves of 234 million boe 2P reserves of over 1.8 billion boe (c.17mn boe of condensate, 153mn boe of gas) Average Ruspetro Production (boepd) 5,000 4,000 4,639 Developed region and infrastructure Experienced management team with proven track record Commercialisation of gas production being 3,000 2,560 developed 2,000 1,000 673 1,055 0 2009 2010 2011 2012 Source: Company Data and D&M. 5

Reserves of International Oil and Gas Companies Compared 1P reserves (mmboe) As per the latest company update, unless stated otherwise 2P reserves (mmboe) As per the latest company update, unless stated otherwise 1,838 927 733 522 520 292 230 210 130 73 RusPetro Dragon Oil Alliance Oil Zhaikmunai Exillon Energy Premier Lundin Afren SOCO Salamander Source: Company data, Bloomberg. 6

2. 2012 Field Review 7

2012 Objectives Reviewed Build a team to efficiently develop, produce and sell hydrocarbons Develop the sales, treatment and access infrastructure required Improve reserve quality by increasing the proved category Develop a strategy to develop and monetize our gas resources Grow production towards a target of 10,400 boepd by the end of the year Refinance debt, extend maturity 8

2012 Results Summary Full year EBITDA of negative US$6.2 million, Q4 2012 EBITDA positive at US$2.4 million 2012 2011 Change % Revenue (US$m) 76.23 38.72 +97% Well head revenue per barrel (US$/boe) 24.50 19.83 +24% Oil and condensate production, total (boe) 1,697,950 935,003 +82% Average production (boe) 4,639 2,560 +81% Proved reserves (mm boe) 234 173 +35% Probable reserves (mm boe) 1,604 1,372 +17% 9

Crude Oil: 2012 Development Review Cross Section 3 Wells Pad 19: More compartmentalized, variable quality 10

Log comparisons 254b, 233, 260 Average reservoir quality: φ = 13.8% Net pay: 17.7 m Initial production rate: Qoil = 62.7 m3/day Average reservoir quality: φ = 14% Net pay: 18 m Initial production rate: Qoil = 320.54 m3/day Average reservoir quality: φ = 14% Net pay: 22.7 m Initial production rate: Qoil = 436.76 m3/day 11

Resolution improvements after Reprocessing - along northern flank of P-I 242 248 239 246 237 24 1 West NE North PAD 021 12

Well 460 (1992) western side of V-I License (north of Pad 25) Crestal location, limited reservoir, 3.3M 3 /D oil from poor UK4? Reprocessed seismic indicates prospective flank positions Poor Imaging: Unclear structural stratigraphic relationship 460 Clear Imaging: Clear faulting with stratigraphic pinchou 460 13

Crude Oil Waterflood Progress - Injection wells - Production wells with Waterflood Response 2012 4 wells converted 2013 4 wells to be converted 14

Oil Production, m3/d Pump Inlet Pressure, bar Oil Production, m3/d Pump Inlet Pressure, bar Waterflood Response Wells 230,236 140 Start Well 22 Injection Start Well 224 Injection 70 120 60 100 50 80 60 40 30 Oil production 230, m3/d Decline 230 Pump Inlet Pressure 230, bar 40 20 20 10 0 Jan-2011 Jul-2011 Jan-2012 Jul-2012 Dec-2012 0 100 90 80 70 100 90 80 70 60 50 40 30 20 10 0 Jan-2011 Jul-2011 Jan-2012 Jul-2012 Dec-2012 60 50 40 30 20 10 0 Oil Production 236, m3/d Decline 236 Pump Inlet Pressure 236, bar 15

Gas/Condensate Review Basement Structure Map sloping talus Source 1 width of the trough Source 2 sloping talus 16

Gas/Condensate Review (cont d) 17

Yield, scm/mmscm Condensate Yield 450 Condensate Yield Vs. vs. Average average Reservoir reservior Pressure pressure 400 350 300 250 Current average Pressure 200 150 100 50 0 50 70 90 110 130 150 170 190 210 230 250 Average reservior pressure, atm * Correlation is based on D&M report Average Reservoir Pressure, atm 18

Average Reservoir Pressure (atmospheres) 19

2012 Field Delineation Summary Discovered 171 million boe (2P) Gas/Condensate play in the north of the field Identified varying permeability across the field requiring different drilling and completion technologies Increased proved reserves by 35% to 234 million boe, increased probable reserves by 17% to 1.6 billion boe Constructed infrastructure to enable accelerated development of proved areas Established new sales routes and off take agreements Developed a sum of the parts development plan for the field to drive future growth 20

Pad 19, 21, 23b. UK2-3 Pad 27. UK2-WZ Pad 32. UK8-10 Prospectivity Map of the Field Pad 25. UK1 (Abalak) UK2-3 Pad 3. UK8-9 Legend Pad 19, 21, 23b. UK2-3 Proved developed Pad 27. UK2-WZ Pad 19, 21, 23b. UK2-3 Pad 27. UK2-WZ Pad 25. UK1 (Abalak) Pad 32. UK8-10 Proved undeveloped Pad 1, 2, 4. Probable Gas condensate UK8-10 Proved Developed Gas condensate Legend Proved undeveloped gas condensate Proved developed Vikulov incised valley Proved undeveloped Vikulov standard Probable Vikulov standard Vikulov incised valley UK2-3 Vikulov standard Proved Developed Gas condensate UK2-3 Proved undeveloped gas condensate Vikulov incised valley Vikulov standard Vikulov incised valley Legend Vikulov standard Proved developed 21

3. Development Plan 22

Current Portfolio and Development Plan Reserves (boe) Current Production (boepd) Development Plan Crude Oil 1,667mm 5,200 Appraise highly prospective western area of the field in Pad 23 area Use fit for purpose technology for lower permeability areas of the field Further expand the water flooding program Re-process seismic data and further develop geological model Drilling Plan Drill gas/condensate wells to characterize the gas reservoir Focus on proven acreage of the field Necessary infrastructure already in place Gas / Condensate / LPG 171mm c.10,000 Gas Treatment Facility Progress discussions/negotiations with various parties (contractors, off-takers) for the monetisation of gas business Construction of Gas treatment facility At current production levels gas/associated products has potential to generate c.$35-65mn revenue per year with minimal opex requirements Bazhenov -- -- Conduct feasibility studies to determine the scale of reserves Preliminary estimates show significant resource potential No MET on production from Bazhenov reserves likely / possible D&M NPV $10.4bn (1) (1) D&M NPV at 10% discount rate. Does not include Bazhenov resources. 23

Crude Oil Development 2013 Pad 23 Appraisal Use 2012 well log data to refine approach to drilling in 2013 Reprocess existing seismic data and refine geological model Design fit for purpose drilling and completion techniques for lower permeability formations Continue to develop waterflood program in Pad 21 area Acquire further 3D seismic MET legislation now being debated by the Duma may change the economics of production in 2014 24

Gas/Condensate Development 2013 Drilling to further characterize gas/condensate reservoir in advance of gas sales sloping talus Source 1 width of the trough Source 2 sloping talus 25

Gas/Condensate Development (cont d) 26

Ruspetro s Bazhenov Shale Oil Position The Bazhenov shale oil unconventional resource is one of the richest source rocks globally covering 2.3mn sq km in West Siberia. Bazhenov relative size vs. global shale Ruspetro s license areas include 1,234 sq km (305,000 acres) of Bazhenov shale with an average thickness of 115 and relatively high TOC. Bazhenov Bakken Eagle Ford Geological age Late Jurrassic Devonian Late Cretaceous Depth 7,500 10,000 11-13,000 Thickness 100-125 100 200-300 Total Organic Content 12% 11% 5% Source: Neftex, Bernstein estimates. Ruspetro s Bazhenov Shale Oil position may provide a large scale development opportunity 27

Preliminary Bazhenov Shale Characterization Commissioned a report by DeGolyer & MacNaughton to assess the potential volumes of the Bazhenov Shale of the Krasnoleninskoye field. Top Bazhenov Structure (3D, 2D & wells) Initial petrophysical, geochemical and basin modeling is complete encompassing size, stratigraphy and structure. Bazhenov Reservoir characterization initially to include two vertical cores and analysis followed by integration of seismic, geological model, cores and logs for optimal well design for a Shale program. Source: Ruspetro, DeGoyler & McNaughton. Ruspetro will continue characterization of Bazhenov in 2013 through its conventional drilling program 28

Ruspetro: Enhanced Business Model Post Construction of GTF Crude Oil Wells Oil Treatment Facility / Storage Tanks Crude Oil 27km RPO Pipeline Transneft System Exports / End Customers Railway Associated Gas Railway End Customer Production Trucks Condensate Pipeline Connection Point End Customer Gas / Condensate Wells Gas Treatment Facility Dry Gas LPG Trucks Railway End Customer 29

4. Financing Plan 30

Market vs. Fundamental Value Value Gap: Market EV and 2P c.$9,900mn $10,437 mn Value Gap: Market EV and 1P - c.$600mn $500 mn $1,157 mn (1) (2) (2) Current Enterprise Value 1P Valuation 2P Valuation Driven by low production growth Funding concerns Large capital expenditure requirements to fully develop the field Proved reserves of 234mn Boe (discount rate 10%) Oil/Condensate: 204mn boe Gas: 29mn boe 90% probability of recoverable reserves (PV10) Proved and Probable reserves of 1,838mn boe Oil/Condensate: 1,684mn boe Gas: 153mn boe 50% probability of recoverable reserves (PV50) Company is considering various strategic options to bridge the gap between fundamental and market valuation (1) Market Enterprise Value as of 8 April 2013; (2) Based on audited D&M reserves valuation 31

Closing The Gap: Strategic Timeline Financial Restructuring Monetisation of Gas Business Develop Crude Oil Restructuring of Steps for gas Gas revenues to finance Sberbank debt monetisation crude development Extension of existing facility Interest waiver / New Facility Long-term off-take contracts Finance and Construct Gas Acceleration may include Risk sharing with international service companies Restore Shareholder Value Other debt / equity Processing Plant Financial farm-in structures as Plan B Financing proposals agreements in negotiation now Different audience Will accelerate or for conventional and monetise Bazhenov opportunistically 32

1,000,000m3 Gas Commercialisation Situation Overview D&M Reserves 30,000 20,000 10,000 0 21,127 4,932 2,337 Proved Probable Possible Current Production Government Regulations Development Plan Revenue Potential (1) Associated gas production is currently 1.6 million cubic meters per day (c.9,000 boepd) due, in large part, to significant gas production in the Palyanovo condensate field Due to lack of processing facilities, we are currently flaring gas production and realising only condensate sales Based on a new regulation, Ruspetro can flare up to 100% of its associated petroleum gas for three years or until our proved and probable reserves are depleted by 5%. Depletion, as at 31 December 2012, is less than 1% of the proved and probable reserves of the field Given that gas is an associated product from our field, there is no MET on gas production We are currently in discussions with various parties (contractors, off-takers) for the monetisation of our gas business / construction of a gas treatment facility ( GTF ) We have signed an Agreement of Intent to supply a regional electricity generator, with dry gas for up to eight years Post commissioning of a GTF, Ruspetro will be able to generate revenues from sale of dry gas and other associated liquids (LPG) At current production level of c.1.6mn cubic meters of gas per day, we have the potential to generate c.$35mn revenue annually from dry gas sales and an additional c.$30mn annually from the sale of associated products (LPG) The field has the potential to produce 1.5bcm per year once the GTF is operational This implies c.$90mn revenue from dry gas sales and c.$80mn from the sale of associated product annually (1) Based on dry gas price of $65/km3 and LPG price of $350/tonne 33

Financial Strategies for Gas Monetisation Own Plant Existing Regional Plant Description Build own gas processing plant and pipelines Process gas using processing plant of another company Capital Expenditure Requirements Plant and pipeline Likely to be c.$200- $250 million Pipeline Low capital expenditure ($60-80mn) Capacity New plant can be customised to capacity requirements Limited initial capacity available Financing Project finance / private debt Vendor financing Minimal financing required Timeline c.18-24 months c.12 months 34

Financial Strategies for Development of Crude Oil Partnerships Financial Farm-in Structure Target Audience International service companies (drillers) Financial investors International service companies International and local oil & gas companies Application Horizontal well program Bazhenov development Development of crude oil using fit for purpose technology Possible Structures Risk sharing agreements proportional to production and capital expenditures Investment at the asset / license level Comments We are currently exploring such structures with various local and international companies 35

5. 2012 Financial Review 36

2012 Cash Flow 31 December 2012 cash balance of US$34.4 million 250.0 200.0 213.7 7.5 1.3 106.6 150.0 100.0 69.2 50.0 3.9 34.4 0.0 1.3 Opening Cash Balance IPO Proceeds Operating Cash Flow Change in Working Capital Capex Loans and Interest Paid Currency Translation Difference Closing Cash Balance 37

2012 Capital Expenditure Item (US$ 000) 2012 IPO Budget Variance Variance, % New wells 66,014 44,400 21,614 +49% Sales pipeline 4,078 8,900 (4,822) -54% Infield pipelines 11,476 4,450 7,026 +158% Power facilities 2,992 8,000 (5,008) -63% Electricity lines 817 1,500 (683) -46% Pad construction 4,881 5,000 (119) -8% Oil processing facilities 6,674 15,650 (8,976) 57% Other field infrastructure 1,689 5,780 (4,091) -71% Other Capital Expenditures 7,962 -- n/a n/a Surface Infrastructure Sub-Total 40,569 49,280 (8,711) -18% Total 106,583 93,680 12,904 +14% 38

$m $m Financing Overview 2012 Year-End Current Debt Structure Restructuring - Currently Under Negotiation 350.0 300.0 250.0 200.0 150.0 100.0 50.0 0.0 289.1 61.8 19.3 Sberbank Limolines Makayla Restructuring of Sberbank Debt Discussions underway to extend the maturity of current debt Debt restructuring may include interest waiver Restructuring of Shareholder loans Company continues to have discussions with the 2013 Debt Servicing Obligations shareholders to extend the maturity of loans or 25 20 20.3 convert them into equity 15 12.5 12.5 10 5 0 May 13 Aug 13 Nov 13 Source: Company data 39

Closing The Gap Financial Restructuring Monetisation of Gas Business Development Of Crude Oil Restore Shareholder Value 40